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US20060123993A1 - System for drying gas and use of the system - Google Patents

System for drying gas and use of the system Download PDF

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Publication number
US20060123993A1
US20060123993A1 US10/546,915 US54691505A US2006123993A1 US 20060123993 A1 US20060123993 A1 US 20060123993A1 US 54691505 A US54691505 A US 54691505A US 2006123993 A1 US2006123993 A1 US 2006123993A1
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US
United States
Prior art keywords
gas
drying
liquid
stage
unit
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US10/546,915
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English (en)
Inventor
Norolf Henriksen
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GROUP 7 TECHNOLOGY AS
Original Assignee
GROUP 7 TECHNOLOGY AS
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
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Application filed by GROUP 7 TECHNOLOGY AS filed Critical GROUP 7 TECHNOLOGY AS
Assigned to GROUP 7 TECHNOLOGY AS reassignment GROUP 7 TECHNOLOGY AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: HENRIKSEN, NOROLF
Publication of US20060123993A1 publication Critical patent/US20060123993A1/en
Abandoned legal-status Critical Current

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/26—Drying gases or vapours
    • B01D53/263—Drying gases or vapours by absorption
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G OR C10K; LIQUIFIED PETROLEUM GAS; USE OF ADDITIVES TO FUELS OR FIRES; FIRE-LIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas

Definitions

  • the present invention concerns a system for drying gas, for example removing moisture (water) from natural gas in connection with the extraction of oil and gas, comprising a drying unit for drying the gas by means of a drying liquid that is mixed with the gas and a regeneration unit that is designed to regenerate the gas.
  • Natural gas that is extracted from oivgas fields at relatively high pressure is usually saturated with water vapour.
  • the water content in the gas can create considerable problems when it is transported through pipelines.
  • the water vapour condenses and may subsequently freeze, blocking the pipelines with ice crystals.
  • the water may also react with hydrocarbons and create ice hydrate, which may also block valves and pipelines.
  • the gas it is necessary for the gas to be extracted to undergo a drying process before it is transported through long pipelines, which are laid on the sea bed, to its destination, which may be a store, processing plant or similar.
  • the quantity of water vapour in the gas must be reduced to such an extent that there is no risk of water being condensed during transport and freezing to form ice.
  • DEG diethylene
  • TEG triethylene
  • TMG tetraethylene
  • TEG is almost the only type used for this purpose.
  • the water absorption process takes place in vertical columns or towers with bases, or filled with filling bodies (Raschig rings), in which a counterflow system is used, i.e. the gas to be dried flows up through the column or tower, while the drying agent, for example TEG, flows down over bases or filling bodies and absorbs water vapour.
  • a counterflow system i.e. the gas to be dried flows up through the column or tower, while the drying agent, for example TEG, flows down over bases or filling bodies and absorbs water vapour.
  • the tower In order to achieve a sufficient degree of drying of the gas in such a tower, the tower must be very high. Moreover, to avoid unfortunate phenomena such as flooding and the like, the diameter of the column/tower must be adjusted relatively precisely. A conventional drying system therefore has relatively large dimensions and is not well suited for use on production ships, for example.
  • the present invention represents a drying system for gas that takes up little space, weighs little and has a low height compared with conventional drying towers.
  • the system in accordance with the present invention will not be sensitive to sea swell either and will therefore be well suited for production ships.
  • the solution in accordance with the present invention is designed to withstand high external pressures, which means that it can be used in connection with submarine installations in connection with, for example, the separation of oil, gas and water.
  • the regeneration unit may expediently be placed on a local platform or ship for practical reasons.
  • the present invention is also based on the use of a liquid, for example TEG, as the drying medium.
  • a liquid for example TEG
  • the present invention is based on the mass transfer taking place in a co flow system.
  • Such a system may comprise one or more processing stages.
  • the present invention is characterised in that the drying unit comprises one or more processing stages, where each stage comprises a mass transfer unit in the form of a static mixer unit or pipe loop in which the gas is mixed with the drying liquid and passed in the direction of flow of the drying liquid to a gas/liquid separator, and where the gas is designed to be passed on to the next stage or on to an outlet, while the drying liquid is passed to the regeneration unit and/or to the next stage, as specified in the attached claim 1 .
  • each stage comprises a mass transfer unit in the form of a static mixer unit or pipe loop in which the gas is mixed with the drying liquid and passed in the direction of flow of the drying liquid to a gas/liquid separator, and where the gas is designed to be passed on to the next stage or on to an outlet, while the drying liquid is passed to the regeneration unit and/or to the next stage, as specified in the attached claim 1 .
  • the process also makes it possible to install coolers 10 to cool the circulating drying liquid and thus to cool the gas indirectly. Keeping the drying liquid cool also increases its water vapour absorption capacity.
  • Each stage therefore consists of a mass transfer unit, a separator for gas/drying medium and a pump for circulation of the drying liquid or drying medium.
  • the mass transfer unit in which water vapour is transferred from the gas to the drying medium may be designed, for example, as vertical sling pipes or static mixers integrated in vertical tubular housings.
  • the function of the separator for gas/drying liquid is to separate the drying liquid from the gas so that the drying liquid can be recirculated back to the mass transfer unit using a pump.
  • the quantity of liquid circulated in each stage may be determined using an optimisation assessment.
  • the process also aims for the quantity of liquid regenerated in relation to the quantity of gas processed to be as in conventional drying systems. This makes it possible to continue to use existing regeneration systems after a conventional system, based on counterflow, has been removed and a co-flow system in accordance with the present invention has been expediently installed as a replacement.
  • the gas flows, propelled by its own pressure, from a relevant gas source (not shown) to an inlet 1 of a first static mixer 2 , where it is mixed with drying liquid and passed on in the direction of flow of the drying liquid to a first gas/liquid separator 3 in the first stage, A, in the system. From the gas/liquid separator 3 in the first stage, A, the gas is passed on to a second static mixer 2 , where it is mixed with drying liquid and passed on in the direction of flow of the drying liquid to a second gas/liquid separator 3 in the second stage, B, and from there, as dried gas mainly free of moisture (water) to an outlet 6 for transport to a store, processing plant or similar (not shown).
  • Drying liquid containing water for example TEG
  • a regeneration unit C After regeneration, the liquid is passed back to the drying system through a pipe 7 to the static mixer 2 in the second processing stage, B, and via a pipe 8 to the static mixer 2 in the first processing stage, A.
  • Circulation pumps 4 which circulate the drying liquid in the system, are arranged at the outlets of each of the gas/liquid separators 3 .
  • the pumps 4 are arranged in such a way that the drying liquid from the regeneration unit C is mixed with the drying liquid from the gas/liquid separator 3 in stage B before distribution to the respective static mixers 2 , while the drying liquid from the gas/liquid separator in stage A is partially passed back to the regeneration unit C and partially back to the static mixer 2 in stage A.
  • the process is also based on a certain pressure drop being acceptable for the gas. Therefore, there is no need for a compressor.
  • the pumps for each stage are dimensioned for optimal mass transfer in the static mixers.
  • the system is intended to use the same quantity of regenerated drying liquid as a conventional: drying tower, i.e. the same type and size of regeneration system may be used.
  • a co-flow system of the above type was tested at a test centre for process technology.
  • the number of stages in the system was 2, and sling pipes were used for mass transfer instead of static mixers.
  • the internal diameter of these pipes was 25 mm. 2 sets of such pipes with a vertical height of 10 metres and a total pipe length per stage of 40 metres were used for each stage.
  • Incoming gas Flow rate: 10 mill. sm 3 /day (5000 m 3 /h) Temperature: 22° C. Pressure: 68 bar g Water vapour pressure in gas: 25 mm Hg Objective: The gas is to be dried to dew point ⁇ 15° C.
  • saturated gas contains approximately 17 times as much water vapour as at ⁇ 15° C.
  • the necessary efficiency for water vapour removal from the gas is then 94%. This is achieved with a single-stage system: with supply of regenerated glycol to the stage: 320 l/h with circulation of glycol in the stage: 4000 l/h

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Analytical Chemistry (AREA)
  • Drying Of Gases (AREA)
  • Drying Of Solid Materials (AREA)
US10/546,915 2003-03-28 2004-03-26 System for drying gas and use of the system Abandoned US20060123993A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20031458A NO20031458D0 (no) 2003-03-28 2003-03-28 Anlegg for gasstörking
NO20031458 2003-03-28
PCT/NO2004/000089 WO2004085037A1 (fr) 2003-03-28 2004-03-26 Systeme pour secher des gaz et utilisation du systeme

Publications (1)

Publication Number Publication Date
US20060123993A1 true US20060123993A1 (en) 2006-06-15

Family

ID=19914620

Family Applications (1)

Application Number Title Priority Date Filing Date
US10/546,915 Abandoned US20060123993A1 (en) 2003-03-28 2004-03-26 System for drying gas and use of the system

Country Status (5)

Country Link
US (1) US20060123993A1 (fr)
BR (1) BRPI0408788B1 (fr)
GB (1) GB2414688B (fr)
NO (1) NO20031458D0 (fr)
WO (1) WO2004085037A1 (fr)

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008099002A1 (fr) * 2007-02-16 2008-08-21 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour réduire des additifs dans un courant d'hydrocarbure
GB2458055A (en) * 2007-02-16 2009-09-09 Shell Int Research Method and apparatus for reducing additives in a hydrocarbon stream
US8491712B2 (en) 2010-09-13 2013-07-23 General Electric Company Dehydration systems and methods for removing water from a gas
US8899557B2 (en) 2011-03-16 2014-12-02 Exxonmobil Upstream Research Company In-line device for gas-liquid contacting, and gas processing facility employing co-current contactors
US10130897B2 (en) 2013-01-25 2018-11-20 Exxonmobil Upstream Research Company Contacting a gas stream with a liquid stream
US10155193B2 (en) 2013-05-09 2018-12-18 Exxonmobil Upstream Research Company Separating impurities from a gas stream using a vertically oriented co-current contacting system
US10300429B2 (en) 2015-01-09 2019-05-28 Exxonmobil Upstream Research Company Separating impurities from a fluid stream using multiple co-current contactors
US10343107B2 (en) 2013-05-09 2019-07-09 Exxonmobil Upstream Research Company Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting systems
US10391442B2 (en) 2015-03-13 2019-08-27 Exxonmobil Upstream Research Company Coalescer for co-current contractors
US10717039B2 (en) 2015-02-17 2020-07-21 Exxonmobil Upstream Research Company Inner surface features for co-current contractors
US10876052B2 (en) 2017-06-20 2020-12-29 Exxonmobil Upstream Research Company Compact contacting systems and methods for scavenging sulfur-containing compounds
US11000797B2 (en) 2017-08-21 2021-05-11 Exxonmobil Upstream Research Company Integration of cold solvent and acid gas removal
US11000795B2 (en) 2017-06-15 2021-05-11 Exxonmobil Upstream Research Company Fractionation system using compact co-current contacting systems
US11260342B2 (en) 2017-06-15 2022-03-01 Exxonmobil Upstream Research Company Fractionation system using bundled compact co-current contacting systems

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE102009041104A1 (de) * 2009-09-14 2011-04-14 Uhde Gmbh Verfahren zum Trocknen von Erdgas durch gemeinsame Kühlung von Lösungsmittel und Erdgas
CN107670500A (zh) * 2017-09-29 2018-02-09 南通万舟船舶机械有限公司 一种船舶尾气的处理装置及其工作方法

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4455157A (en) * 1981-01-23 1984-06-19 Latoka Engineering, Inc. Absorber for dehydrating gas
US6699308B1 (en) * 1999-03-23 2004-03-02 Statoil Asa Method and apparatus for the drying of natural gas

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4279628A (en) * 1979-12-31 1981-07-21 Energy Synergistics, Inc. Apparatus for drying a natural gas stream
EP1021238A1 (fr) * 1997-09-15 2000-07-26 Den Norske Stats Oljeselskap A.S. Systeme de separation de fluide

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4455157A (en) * 1981-01-23 1984-06-19 Latoka Engineering, Inc. Absorber for dehydrating gas
US6699308B1 (en) * 1999-03-23 2004-03-02 Statoil Asa Method and apparatus for the drying of natural gas

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008099002A1 (fr) * 2007-02-16 2008-08-21 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour réduire des additifs dans un courant d'hydrocarbure
GB2458055A (en) * 2007-02-16 2009-09-09 Shell Int Research Method and apparatus for reducing additives in a hydrocarbon stream
US20100140144A1 (en) * 2007-02-16 2010-06-10 Paul Clinton Method and apparatus for reducing additives in a hydrocarbon stream
AU2008214557B2 (en) * 2007-02-16 2010-09-30 Shell Internationale Research Maatschappij B.V. Method and apparatus for reducing additives in a hydrocarbon stream
GB2458055B (en) * 2007-02-16 2011-06-08 Shell Int Research Method and apparatus for reducing additives in a hydrocarbon stream
EA016012B1 (ru) * 2007-02-16 2012-01-30 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Способ и устройство для уменьшения содержания добавок в углеводородном потоке
US8445737B2 (en) 2007-02-16 2013-05-21 Shell Oil Company Method and apparatus for reducing additives in a hydrocarbon stream
US8779223B2 (en) 2007-02-16 2014-07-15 Shell Oil Company Method and apparatus for reducing additives in a hydrocarbon stream
US8491712B2 (en) 2010-09-13 2013-07-23 General Electric Company Dehydration systems and methods for removing water from a gas
US8899557B2 (en) 2011-03-16 2014-12-02 Exxonmobil Upstream Research Company In-line device for gas-liquid contacting, and gas processing facility employing co-current contactors
US10130897B2 (en) 2013-01-25 2018-11-20 Exxonmobil Upstream Research Company Contacting a gas stream with a liquid stream
US10155193B2 (en) 2013-05-09 2018-12-18 Exxonmobil Upstream Research Company Separating impurities from a gas stream using a vertically oriented co-current contacting system
US10343107B2 (en) 2013-05-09 2019-07-09 Exxonmobil Upstream Research Company Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting systems
US10300429B2 (en) 2015-01-09 2019-05-28 Exxonmobil Upstream Research Company Separating impurities from a fluid stream using multiple co-current contactors
US10717039B2 (en) 2015-02-17 2020-07-21 Exxonmobil Upstream Research Company Inner surface features for co-current contractors
US10391442B2 (en) 2015-03-13 2019-08-27 Exxonmobil Upstream Research Company Coalescer for co-current contractors
US10486100B1 (en) 2015-03-13 2019-11-26 Exxonmobil Upstream Research Company Coalescer for co-current contactors
US11000795B2 (en) 2017-06-15 2021-05-11 Exxonmobil Upstream Research Company Fractionation system using compact co-current contacting systems
US11260342B2 (en) 2017-06-15 2022-03-01 Exxonmobil Upstream Research Company Fractionation system using bundled compact co-current contacting systems
US10876052B2 (en) 2017-06-20 2020-12-29 Exxonmobil Upstream Research Company Compact contacting systems and methods for scavenging sulfur-containing compounds
US11000797B2 (en) 2017-08-21 2021-05-11 Exxonmobil Upstream Research Company Integration of cold solvent and acid gas removal

Also Published As

Publication number Publication date
BRPI0408788B1 (pt) 2015-12-08
GB2414688B (en) 2006-12-06
BRPI0408788A (pt) 2006-03-28
WO2004085037A1 (fr) 2004-10-07
GB2414688A (en) 2005-12-07
GB0517444D0 (en) 2005-10-05
NO20031458D0 (no) 2003-03-28

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AS Assignment

Owner name: GROUP 7 TECHNOLOGY AS, NORWAY

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:HENRIKSEN, NOROLF;REEL/FRAME:017408/0050

Effective date: 20050923

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION